AU687606B2 - Cryogenic coal bed gas well stimulation method - Google Patents
Cryogenic coal bed gas well stimulation methodInfo
- Publication number
- AU687606B2 AU687606B2 AU32439/95A AU3243995A AU687606B2 AU 687606 B2 AU687606 B2 AU 687606B2 AU 32439/95 A AU32439/95 A AU 32439/95A AU 3243995 A AU3243995 A AU 3243995A AU 687606 B2 AU687606 B2 AU 687606B2
- Authority
- AU
- Australia
- Prior art keywords
- coal seam
- liquid nitrogen
- wellbore
- tubing
- gas
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Ceased
Links
- 239000003245 coal Substances 0.000 title claims description 64
- 238000000034 method Methods 0.000 title claims description 39
- 230000000638 stimulation Effects 0.000 title description 9
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 152
- 229910052757 nitrogen Inorganic materials 0.000 claims description 75
- 239000007788 liquid Substances 0.000 claims description 63
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 28
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 28
- 239000007789 gas Substances 0.000 claims description 26
- 238000002347 injection Methods 0.000 claims description 20
- 239000007924 injection Substances 0.000 claims description 20
- 238000004519 manufacturing process Methods 0.000 claims description 11
- 239000011152 fibreglass Substances 0.000 claims description 8
- 239000000126 substance Substances 0.000 claims description 8
- 238000011282 treatment Methods 0.000 claims description 7
- HSFWRNGVRCDJHI-UHFFFAOYSA-N alpha-acetylene Natural products C#C HSFWRNGVRCDJHI-UHFFFAOYSA-N 0.000 claims description 4
- 230000004888 barrier function Effects 0.000 claims description 4
- 125000002534 ethynyl group Chemical group [H]C#C* 0.000 claims description 4
- 239000002245 particle Substances 0.000 claims description 3
- 239000008188 pellet Substances 0.000 claims description 3
- 230000008569 process Effects 0.000 description 19
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 10
- 230000015572 biosynthetic process Effects 0.000 description 8
- 238000005755 formation reaction Methods 0.000 description 8
- 239000012530 fluid Substances 0.000 description 6
- 239000010935 stainless steel Substances 0.000 description 6
- 229910001220 stainless steel Inorganic materials 0.000 description 6
- 229910002092 carbon dioxide Inorganic materials 0.000 description 5
- 239000001569 carbon dioxide Substances 0.000 description 5
- 239000000463 material Substances 0.000 description 4
- 229910000831 Steel Inorganic materials 0.000 description 3
- 230000008901 benefit Effects 0.000 description 3
- 239000013078 crystal Substances 0.000 description 3
- 239000010959 steel Substances 0.000 description 3
- 230000008646 thermal stress Effects 0.000 description 3
- 230000006378 damage Effects 0.000 description 2
- 239000002360 explosive Substances 0.000 description 2
- 239000011159 matrix material Substances 0.000 description 2
- 238000005065 mining Methods 0.000 description 2
- 230000035699 permeability Effects 0.000 description 2
- 238000010926 purge Methods 0.000 description 2
- 239000004576 sand Substances 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 230000004936 stimulating effect Effects 0.000 description 2
- 230000008961 swelling Effects 0.000 description 2
- 230000008016 vaporization Effects 0.000 description 2
- 229910000975 Carbon steel Inorganic materials 0.000 description 1
- 239000010962 carbon steel Substances 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000011284 combination treatment Methods 0.000 description 1
- 230000001351 cycling effect Effects 0.000 description 1
- 229910001873 dinitrogen Inorganic materials 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000006260 foam Substances 0.000 description 1
- 230000008014 freezing Effects 0.000 description 1
- 238000007710 freezing Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- JCXJVPUVTGWSNB-UHFFFAOYSA-N nitrogen dioxide Inorganic materials O=[N]=O JCXJVPUVTGWSNB-UHFFFAOYSA-N 0.000 description 1
- 230000002028 premature Effects 0.000 description 1
- 239000000376 reactant Substances 0.000 description 1
- 230000009257 reactivity Effects 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000001881 scanning electron acoustic microscopy Methods 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 239000007921 spray Substances 0.000 description 1
- 238000005507 spraying Methods 0.000 description 1
- 230000035882 stress Effects 0.000 description 1
- 230000003685 thermal hair damage Effects 0.000 description 1
- 238000009834 vaporization Methods 0.000 description 1
- 238000010792 warming Methods 0.000 description 1
- 230000003313 weakening effect Effects 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/003—Insulating arrangements
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/006—Production of coal-bed methane
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/2605—Methods for stimulating production by forming crevices or fractures using gas or liquefied gas
Landscapes
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Chemical & Material Sciences (AREA)
- General Chemical & Material Sciences (AREA)
- Filling Or Discharging Of Gas Storage Vessels (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
Description
CRYOGENIC COAL BED GAS WELL STIMULATION METHOD
BACKGROUND OF THE INVENTION
FIELD OF THE INVENTION This invention relates to recovery of methane gas from subterranean coal seams. More particularly, the invention relates to a process wherein cryogenic liquid such as liquid nitrogen is utilized to increase the permeability of the portion of a coal seam penetrated by a wellbore.
DESCRIPTION OF THE PRIOR ART Subterranean coal seams typically contain large volumes of methane. In the case of a mineable coal seam, it is desirable from a safety standpoint to produce as much of the methane as possible before beginning mining operations. In deeper coal seams, not amenable to conventional mining techniques, the methane constitutes a recoverable energy source which can be produced by conventional gas production methods. Presently, methane is produced through wells drilled into the coal seams. Once a well is drilled and completed, it is common to treat the coal seam in order to stimulate the production of methane therefrom. One commonly used stimulation treatment involves hydraulically fracturing the coal seam much in the way other more conventional gas bearing formations are fractured. However, conventional hydraulic fracturing processes involve producing the fracturing fluid back through the wellbore, and this sometimes leaves permeability-reducing debris in the formation, and proppant sand often plugs horizontal wells. Gaseous fracturing fluids produce problems because of inability to adequately carry proppants
and flow diverters, and foam fracturing fluids often leave flow-reducing residues. Also, sand or similar proppants sometimes produce back, plugging the well and/or damaging surface production equipment. Another technique which has been proposed for stimulating a coal seam is one which is sometimes referred to as "cavity induced stimulation". In one form of that process, a wellbore is charged with a gas followed by a water slug. The well pressure is then reduced and the injected gas and water produce back and create a cavity by breaking up coal around the borehole face.
Cycling of the gas-water injection and blowdown followed by debris cleanout produces an enlarged wellbore cavity. However, this technique is not effective on many coal seams.
A variation of the cavity induced stimulation process in which liquid carbon dioxide is injected into the coal seam is described in U.S. Patent No. 5,147,111 to Montgomery. A method of stimulating water flow from a dry well is described in U.S. Patent No.4,534,413. That method involves alternate pressurization and depressurization of a well with liquid or gaseous nitrogen or carbon dioxide to fracture the borehole surface. While the above-described processes have improved methane production in many cases, there remains a need for an improved stimulation process which is cheaper, safer and more effective than currently available processes.
SUMMARY OF THE INVENTION
According to the present invention, a coal seam gas production stimulation process is provided that effectively improves methane production rates even from coal seams that are not responsive to conventional stimulation procedures.
An essential feature of this invention is the use of liquid nitrogen to treat the near wellbore area of a coal seam. The extreme cold of liquid nitrogen, combined with the low thermal conductivity of coal and the shrinkage of coal at lowered temperature, creates a severe thermal stress area where warm coal meets cold coal. The resulting stress causes the coal to become weak and friable. Also, the water within the coal matrix is quickly frozen at the point of contact with liquid nitrogen, and the resulting swelling during ice formation contributes to crumbling and disintegration of the coal. Further, liquid nitrogen has a very low viscosity, and will penetrate into cleats, fractures and voids, where expansion of nitrogen as it warms further contributes to weakening and fracturing of the coal.
A further essential feature of the invention involves providing a heat transfer barrier between the liquid nitrogen which is pumped down a well tubing and the portion of the well outside the tubing. Wells to be treated generally are lined with a steel casing, and without a heat transfer barrier the temperature generated by the injected liquid nitrogen flowing through the well tubing could cause the well casing to fail. Also, a high rate of heat transfer through the tubing could cause an excessive amount of liquid nitrogen vaporization in the tubing. A twofold approach to creating a heat transfer barrier involves (1) using a tubing having a low thermal conductivity (preferably fiberglass tubing, which maintains its strength at liquid nitrogen temperature) , and (2) flowing a warm gas down the well annulus during liquid nitrogen injection to insulate the well casing from the cold tubing.
In one aspect, a modified "cavity induced stimulation" is used in which a gas (air or gaseous nitrogen) is injected into the near wellbore portion of the coal seam. A slug of water follows the gas injection, and
after the water is displaced into the wellbore face it is followed with a slug of liquid nitrogen. The nitrogen freezes the borehole coal surface as well as the water near the face. The well is then depressurized, and the pressure in the coal seam acts to blow the wellbore skin into the wellbore and create a cavity. The procedure can be repeated as desired with cleanout of debris as appropriate. It has been found that repeated contact of coal with liquid nitrogen results in progressively smaller coal particles. In a modification of the above process, either in addition to or in lieu of the steps described, the coal seam is injected with liquid nitrogen at formation fracturing pressure. In a further variation, the liquid nitrogen can include water ice particles which act as a temporary proppant for the fracturing process. The coal seam is a heat source for the liquid nitrogen, and as the nitrogen flows into newly created fractures it will be vaporized. The expansion will contribute to the fracturing energy. A particular advantage of this process is that the fracturing fluid is produced back as a gas, avoiding the potential for formation damage which some fracturing fluids cause.
In still another aspect of the invention, a difficult to handle treatment chemical can be incorporated in the liquid nitrogen and transported to the coal seam. For example, acetylene gas is unstable at pressures over 80 psig, but it can be frozen into solid pellets and pumped in with liquid nitrogen. When the acetylene warms, it will be in an area where the pressure is several hundred psi, and it will explode violently of its own accord, providing a type of explosive fracturing not heretofore available.
DESCRIPTION OF THE PREFERRED EMBODIMENTS An essential feature of this invention involves transporting liquid nitrogen from a source to a coal seam. Ordinary steel is not suitable for this service, so other
materials must be utilized. Stainless steel piping can be used to transfer liquid nitrogen to a wellhead manifold (also of stainless steel) , and a tubing string of fiber glass pipe or its equivalent connected to the manifold and extending down the well is a preferred mode. Fiber glass tubing preferred over stainless steel tubing because it is a lower cost, lighter weight and lower thermal conductivity material than stainless steel. The manifold preferably includes provisions for flowing material from several sources into the tubing string.
All embodiments of this invention involve injection of liquid nitrogen down the wellbore. There has been concern that the extremely low temperatures involved could damage the ordinary steel casings typically used to complete the wells. The casings normally extend to the top of the coal seam. This problem is overcome by injecting a flow of warm air or nitrogen gas downward through the annulus formed by the well casing and the fiber glass tubing when liquid nitrogen is being injected down the tubing.
There are many advantages to using liquid nitrogen as opposed to liquid carbon dioxide in the process. Primarily, liquid nitrogen is much colder than liquid carbon dioxide. Also, nitrogen is inert to coal, whereas carbon dioxide is reactive with coal and can cause swelling with resultant permeability reduction.
BOREHOLE ENLARGEMENT EMBODIMENT
In this embodiment, a gas such as air or nitrogen is first injected into the near wellbore area of a coal seam. The gas is followed by a water slug, which is then displaced into the near wellbore area, such as by injection of gaseous nitrogen down the injection tubing. After the injection tubing and borehole are substantially free of water, liquid nitrogen is injected down the tubing to contact the borehole face and create thermal stresses at
the borehole face. The liquid nitrogen thermally weakens the contacted coal and also freezes the water in the coal immediately surrounding the wellbore, creating a temporary face skin at least partially sealing the borehole surface to flow in either direction. At least while liquid nitrogen is being pumped down the tubing, warm gas is simultaneously injected down the annulus to insulate the well casing from the low temperature created by liquid nitrogen flowing down the tubing. After injection of liquid nitrogen is complete, the well is depressured, and the combination of natural coal seam pressure and the gas injected into the coal seam acts to blow out the wellbore surface face, which as mentioned previously has been weakened by thermal stresses and the expansion forces of water freezing in the coal matrix.
The process may be repeated several times, depending on the extent of cavity enlargement desired. The resulting debris may be removed one or more times prior to placing the well on methane production.
COAL SEAM FRACTURING EMBODIMENT In this embodiment, which may be in addition to the above-described cavity enlargement process, or which may be a stand-alone process, liquid nitrogen is injected down the wellbore through a fiberglass tubing or its equivalent, while gaseous air or preferably gaseous nitrogen is injected down the well through the annulus formed by the well casing and tubing. The liquid nitrogen is pumped at fracturing pressure, and the thermal effects enhance the fracturing as liquid nitrogen is forced into a new fracture, newly exposed warm coal is contacted, vaporizing some nitrogen to increase or support the fracturing pressure. The fiberglass tubing has low heat conductivity and capacity, so only a small amount of the liquid nitrogen
is vaporized in the tubing during the pump down.
In a particularly preferred embodiment, water ice crystals are utilized as a temporary proppant and flow diverter in the fracturing process. The crystals may be formed by spraying water into the liquid nitrogen either in the well or at the surface. A major advantage in the process is that the nitrogen will vaporize and the ice will melt and/or vaporize so that both will flow back without leaving a permeability-damaging residue as conventional fracturing fluids do.
In a further variation of the fracturing process, a water slug may precede the nitrogen injection. The water tends to fill existing fractures and as it would quickly freeze on contact with liquid nitrogen it would prevent premature leak off and also act as a flow diverter. When a water slug precedes the nitrogen, the water has to be cleared from the injection tubing and from the borehole prior to liquid nitrogen injection to prevent ice formation and plugging. This is preferably done by following the water slug with a gas purging step.
THE CHEMICAL TREATMENT EMBODIMENT In this embodiment, a treatment chemical which is difficult to handle at ambient conditions, because of volatility or reactivity, for example, can be incorporated in a liquid nitrogen stream which allows for safe handling and injection of the chemical.
When the injected chemical is warmed by the formation to be treated, the desired reaction can take place safely. For example, acetylene gas is unstable at pressures above 15 psi, but it can be frozen into solid pellets with liquid nitrogen and pumped into a well. When it is warmed by the formation, it will be at a pressure of several hundred psi and will explode violently without the need for a co-reactant or detonator. The resulting explosive fracturing may be part of a combination treatment
or an independent process. As in the other embodiments, injection of a warm gas through the well annulus during liquid nitrogen injection through the tubing prevents thermal damage to the well casing.
DESCRIPTION OF EQUIPMENT The extremely low temperature of liquid nitrogen presents special problems in carrying out the invention. Ordinary carbon steel is not suitable for cryogenic service, so the injection tubing must be specially designed. A preferred tubing material is fiberglass piping, which maintains its strength at liquid nitrogen temperatures, and has a low heat conductivity. Tubing centralizers are preferably used to maintain uniform spacing between the tubing and the well casing. The tubing is adapted to connect to an above ground manifold, which can be of stainless steel, and stainless steel or other appropriate cryogenic piping can extend from the manifold to the liquid nitrogen source. The liquid nitrogen source is preferably one or more transportable tanks, each of which is connected to the manifold. A gaseous nitrogen source also may be connected to the manifold by appropriate means. The gaseous nitrogen source preferably is a liquid nitrogen tank with a heat exchanger at the tank's discharge for warming and gasifying the nitrogen. A water source may also be connected to the manifold if water is to be injected. The manifold needs to be capable of directing gaseous nitrogen down both the well annulus to provide low temperature protection for the casing, and down the tubing to purge water from the tubing to prevent plugging of the tubing with ice.
A spray injector to provide ice crystals in the liquid nitrogen or to add a treatment chemical to the liquid nitrogen may be located in the well or above ground as appropriate.
The foregoing description of the preferred embodiments is intended to be illustrative rather than limiting of the invention, which is to be defined by the appended claims.
Claims (11)
- Claim 1. A method for improving methane production from a cased wellbore extending into a subterranean coal seam comprising:(a) providing a tubing in said wellbore for conveying liquid nitrogen from the surface to said coal seam;(b) providing a heat transfer barrier between the wellbore casing and the interior of said tubing; (c) injecting liquid nitrogen through said tubing to said coal seam whereby the face of said wellbore adjacent said coal seam is contacted with liquid nitrogen; and (d) producing methane gas from said coal seam through said wellbore.
- Claim 2. The method of Claim 1 wherein a gas is injected into said coal seam adjacent said wellbore prior to said injection of liquid nitrogen.
- Claim 3. The method of Claim 2 wherein water is injected into said coal seam adjacent said wellbore after said injection of gas and prior to said injection of liquid nitrogen.
- Claim 4. The method of Claim 1 wherein said coal seam adjacent said wellbore is contacted with liquid nitrogen a plurality of times followed by production of methane therefrom.
- Claim 5. The method of Claim 1 wherein said liquid nitrogen contains an added treatment chemical which is reactive in said wellbore after injection thereinto.
- Claim 6. The method of Claim 5 wherein said treatment chemical comprises pellets of frozen acetylene.
- Claim 7. The method of Claim 1 wherein said liquid nitrogen is injected into said coal seam at a pressure exceeding the fracture pressure of said coal seam.
- Claim 8. The method of Claim 7 wherein said liquid nitrogen includes water ice particles.
- Claim 9. The method of Claim 1 wherein a gas is flowed down the annulus between said casing and said tubing during injection of said liquid nitrogen.
- Claim 10. The method of Claim 9 wherein said tubing is fiber glass tubing.
- Claim 11. A method of improving methane production from a wellbore extending into a subterranean coal bed comprising:(a) providing a wellbore from the surface through said coal seam;(b) casing said wellbore from the surface to adjacent the top of said coal seam;(c) providing a tubing string through said wellbore from the surface to a point adjacent said coal seam;(d) charging said coal seam by injecting a gas down said wellbore and into said coal seam; (e) injecting a slug of water into said coal seam behind said injected gas;(f) injecting a gas behind said water slug to clear water from said tubing and wellbore;(g) injecting liquid nitrogen into said coal seam at fracturing pressure;(h) displacing liquid nitrogen into said coal seam from said tubing and borehole;(i) closing said well to enable said liquid nitrogen to warm up and vaporize; and (j) opening said well to enable vaporized nitrogen to flow out followed by production of methane gas from said well.
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US356593 | 1994-12-14 | ||
US08/356,593 US5464061A (en) | 1994-12-14 | 1994-12-14 | Cryogenic coal bed gas well stimulation method |
PCT/US1995/010273 WO1996018801A1 (en) | 1994-12-14 | 1995-08-11 | Cryogenic coal bed gas well stimulation method |
Related Child Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
AU16243/97A Division AU1624397A (en) | 1994-12-14 | 1997-03-12 | Cryogenic well stimulation method |
Publications (2)
Publication Number | Publication Date |
---|---|
AU3243995A AU3243995A (en) | 1996-07-03 |
AU687606B2 true AU687606B2 (en) | 1998-02-26 |
Family
ID=23402103
Family Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
AU32439/95A Ceased AU687606B2 (en) | 1994-12-14 | 1995-08-11 | Cryogenic coal bed gas well stimulation method |
AU16243/97A Abandoned AU1624397A (en) | 1994-12-14 | 1997-03-12 | Cryogenic well stimulation method |
Family Applications After (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
AU16243/97A Abandoned AU1624397A (en) | 1994-12-14 | 1997-03-12 | Cryogenic well stimulation method |
Country Status (3)
Country | Link |
---|---|
US (1) | US5464061A (en) |
AU (2) | AU687606B2 (en) |
WO (1) | WO1996018801A1 (en) |
Families Citing this family (18)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5653287A (en) * | 1994-12-14 | 1997-08-05 | Conoco Inc. | Cryogenic well stimulation method |
US20060065400A1 (en) * | 2004-09-30 | 2006-03-30 | Smith David R | Method and apparatus for stimulating a subterranean formation using liquefied natural gas |
US8614171B2 (en) * | 2006-01-04 | 2013-12-24 | Halliburton Energy Services, Inc. | Compositions for stimulating liquid-sensitive subterranean formations |
US7757770B2 (en) * | 2007-02-27 | 2010-07-20 | Conocophillips Company | Method of stimulating a coalbed methane well |
US8839875B2 (en) * | 2009-12-28 | 2014-09-23 | Ben M. Enis | Method and apparatus for sequestering CO2 gas and releasing natural gas from coal and gas shale formations |
WO2012092404A1 (en) | 2010-12-28 | 2012-07-05 | Enis Ben M | Method and apparatus for using pressure cycling and cold liquid co2 for releasing natural gas from coal and shale formations |
EP2527586A1 (en) | 2011-05-27 | 2012-11-28 | Shell Internationale Research Maatschappij B.V. | Method for induced fracturing in a subsurface formation |
CN103015997B (en) * | 2013-01-16 | 2015-05-27 | 西南石油大学 | Filtration plugging testing apparatus and simulation method for process of fracture temporary plugging by ice crystals |
CN103726819B (en) * | 2013-12-27 | 2016-02-24 | 中国石油大学(华东) | Cryogenic gas assists the method for CBM Fracturing technique |
CN104963660B (en) * | 2015-07-17 | 2017-10-24 | 煤炭科学技术研究院有限公司 | The coal bed methane exploring method that a kind of frozen-thawed cracking coal seam is anti-reflection |
CN104963674B (en) * | 2015-07-17 | 2018-03-02 | 煤炭科学技术研究院有限公司 | Hypotonic coal seam frozen-thawed cracking anti-reflection method |
CA3038985C (en) | 2016-11-11 | 2021-02-02 | Halliburton Energy Services, Inc. | Storing and de-liquefying liquefied natural gas (lng) at a wellsite |
CA3038988C (en) | 2016-11-11 | 2021-02-16 | Halliburton Energy Services, Inc. | Treating a formation with a chemical agent and liquefied natural gas (lng) de-liquefied at a wellsite |
CN108424758A (en) * | 2018-03-29 | 2018-08-21 | 中国石油集团川庆钻探工程有限公司长庆井下技术作业公司 | A kind of anti-freeze type insulating liquid and preparation method and application |
CN109707360B (en) * | 2018-12-06 | 2019-11-19 | 中国矿业大学 | A kind of compound fracturing method of high pressure nitrogen-low temperature liquid nitrogen for frscturing |
CN111042782B (en) * | 2019-11-29 | 2022-04-26 | 中石油煤层气有限责任公司 | Method for recovering production of coal bed gas well |
CN115163021B (en) * | 2022-07-13 | 2023-11-03 | 中国矿业大学 | Water injection and nitrogen injection gas extraction hole sealing device and drilling arrangement method |
CN115522905B (en) * | 2022-11-24 | 2023-04-07 | 中国石油大学(华东) | Methane explosion fracturing device for shale gas reservoir and control method thereof |
Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4400034A (en) * | 1981-02-09 | 1983-08-23 | Mobil Oil Corporation | Coal comminution and recovery process using gas drying |
US4534413A (en) * | 1984-12-27 | 1985-08-13 | Igor Jaworowsky | Method and apparatus for water flow stimulation in a well |
US5147111A (en) * | 1991-08-02 | 1992-09-15 | Atlantic Richfield Company | Cavity induced stimulation method of coal degasification wells |
Family Cites Families (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4391327A (en) * | 1981-05-11 | 1983-07-05 | Conoco Inc. | Solvent foam stimulation of coal degasification well |
US4544037A (en) * | 1984-02-21 | 1985-10-01 | In Situ Technology, Inc. | Initiating production of methane from wet coal beds |
US5085274A (en) * | 1991-02-11 | 1992-02-04 | Amoco Corporation | Recovery of methane from solid carbonaceous subterranean of formations |
-
1994
- 1994-12-14 US US08/356,593 patent/US5464061A/en not_active Expired - Lifetime
-
1995
- 1995-08-11 AU AU32439/95A patent/AU687606B2/en not_active Ceased
- 1995-08-11 WO PCT/US1995/010273 patent/WO1996018801A1/en active Search and Examination
-
1997
- 1997-03-12 AU AU16243/97A patent/AU1624397A/en not_active Abandoned
Patent Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4400034A (en) * | 1981-02-09 | 1983-08-23 | Mobil Oil Corporation | Coal comminution and recovery process using gas drying |
US4534413A (en) * | 1984-12-27 | 1985-08-13 | Igor Jaworowsky | Method and apparatus for water flow stimulation in a well |
US5147111A (en) * | 1991-08-02 | 1992-09-15 | Atlantic Richfield Company | Cavity induced stimulation method of coal degasification wells |
Also Published As
Publication number | Publication date |
---|---|
AU3243995A (en) | 1996-07-03 |
US5464061A (en) | 1995-11-07 |
WO1996018801A1 (en) | 1996-06-20 |
AU1624397A (en) | 1997-05-15 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US5653287A (en) | Cryogenic well stimulation method | |
AU687606B2 (en) | Cryogenic coal bed gas well stimulation method | |
US5147111A (en) | Cavity induced stimulation method of coal degasification wells | |
CA2038290C (en) | Method of increasing the rate of production of methane from a coal seam | |
CN103061731B (en) | By the method for steam and carbon dioxide producing viscous hydrocarbon | |
CN105625946B (en) | Coal bed gas horizontal well supercritical CO2Jet stream makes chamber and multistage synchronizes explosion fracturing method | |
US5027896A (en) | Method for in-situ recovery of energy raw material by the introduction of a water/oxygen slurry | |
US7775281B2 (en) | Method and apparatus for stimulating production from oil and gas wells by freeze-thaw cycling | |
US3948323A (en) | Thermal injection process for recovery of heavy viscous petroleum | |
CN106437669B (en) | A kind of thermal cracking seam method and system for deep hot dry rock formation production | |
CN105507871A (en) | Horizontal well liquid nitrogen ice crystal temperature plugging staged fracturing method for coalbed methane | |
US8448708B2 (en) | Method and apparatus for freeze-thaw well stimulation using orificed refrigeration tubing | |
CN112145144B (en) | Based on multistage liquid CO2Phase-change composite fracturing transformation system and method | |
CN107476807A (en) | A kind of coal seam tight roof fracturing method for weakening | |
CA2567399C (en) | Method and apparatus for stimulating heavy oil production | |
US20060162923A1 (en) | Method for producing viscous hydrocarbon using incremental fracturing | |
GB2112835A (en) | Carbon dioxide fracturing process | |
US9556719B1 (en) | Methods for recovering hydrocarbons from shale using thermally-induced microfractures | |
CA2588297C (en) | Method and apparatus for stimulating production from oil and gas wells by freeze-thaw cycling | |
CA2165150C (en) | Cryogenic stimulation method | |
GB2329662A (en) | Cryogenic well stimulation method | |
CN107165576A (en) | Well system | |
US4157847A (en) | Method and apparatus for utilizing accumulated underground water in the mining of subterranean sulphur | |
US3366176A (en) | Recovery of high viscosity oils by conduction heating | |
CA2476827C (en) | Burn assisted fracturing of underground coal bed |